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horizontal drilling practices while running dp
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1/68© K&M Technology Group - 2008
This is the most important subject of this school– The practices used by most groups are completely inappropriate– The serious problems experienced are self-inflicted, and
unnecessary
This section will cover:What is required for safe tripping
PracticesBHA requirements
BackreamingIs it good or bad ?Why do you see what you do ?How to do it safely (and when to do it)
Tripping & Backreaming Practices
2/68© K&M Technology Group - 2008
Tripping & Backreaming Practices• Back-reaming or pumping out should be avoided
whenever possible in high-angle wells– The ability to trip out without pumping or backreaming is a
critical objective– Choosing any practice or equipment that forces you to
backream to trip out makes a mockery of risk-management• Because back-reaming and/or pumping out are the single-most
dangerous operation in any ER well– Maximum risk of stuck pipe, and of destabilizing the wellbore– It is also time consuming, and destructive on BHA equipment
– Engineers :• It’s not just a matter of circulating more … it’s a design issue too
3/68© K&M Technology Group - 2008
Classic train-wreck story
• K&M see / review a lot of high-angle train wrecks– Most have almost identical chain-of-events– 2 common themes :
• Those that had bad hole cleaning while drilling (but they thought it was good). These also tend to have poor tripping practices.
– More common with motor BHAs– Note – Can have good hole cleaning with motors !!
• Those that had good hole cleaning while drilling, but still have poor tripping practices.
– This has become the most common of the two, ever since RSS became popular
– Does the following sound familiar ?
4/68© K&M Technology Group - 2008
Say operator is drilling high or medium angle hole
1. No problems drilling to TD• Good hole cleaning while drilling, and no cavings reported
• How do they know it was good hole cleaning ?
• No tight hole at connections
• Good cuttings flow
5/68© K&M Technology Group - 2008
2. At TD, hole is cleaned up• Multiple bottoms up circulated at TD
• Shakers clean up quite soon … team thinks hole must be clean
• In reality, hole cleaning system has shut down when low-RPM used for clean-up cycle
3. Trip commences• Soon pulls tight.
• Attempt to back-ream thru tight spot
• Hole packs off (initiating circulation or soon after)
• 1st cavings reported at this point
6/68© K&M Technology Group - 2008
4. Back-reaming continues …• Packing off all the way to the shoe
• Relatively little cuttings while back-reaming, until ≈ 30o, then shakers blind with lot’s of cuttings… and cavings.
• Packs off also inside casing
5. Trip Back In
• For some reason, the trip back-in is whistle-clean…despite the nightmarish trip out…
7/68© K&M Technology Group - 2008
Tripping & Backreaming Practices
What we will cover in this section:• Part 1 – What is happening downhole• Part 2 – How to enable tripping on elevators• Part 3 – Tripping procedures• Part 4 – Backreaming procedures
8/68© K&M Technology Group - 2008
Tripping & Backreaming Practices
• Part 1 – What is happening downhole– How does the cuttings bed & BHA interact when tripping ?
• Trouble-free tripping, vs tight hole• Normal tripping vs. Back-reaming vs. Pumping Out
– Separating myth from reality– Why do we see what we see ?
9/68© K&M Technology Group - 2008
What happens downhole when POOH ?
Most people visualize that tripping looks something like this …
And that “tight hole” looks like this …
If this is correct, then normal reactions are valid• Drop down a few feet, and commence back-reaming thru obstruction
10/68© K&M Technology Group - 2008
What really happens downhole when POOH ?
What happens downhole when tripping in a deviated well ?– Firstly, assume that the hole is NOT 100% clean
– Even with a thorough clean-up– Even with Rotary Steering Tools !
– The BHA does NOT pull cuttings up the hole– Cuttings flow around the BHA, until they become too compressed– BHA design is critical to “flow around” ability– Has significant implications for how to manage tight hole
11/68© K&M Technology Group - 2008
What happens downhole when POOH ?
• When pulling out, the BHA pulls up through the dirt …• For a trouble-free trip, the dirt must flow around the BHA as the
BHA moves through the bed
Video Clip
12/68© K&M Technology Group - 2008
What really happens downhole when POOH ?
The dirt must be able to flow through the bit & BHA• Just like mud, we have a serious problem when the dirt can’t get past the BHA• Consider ketchup / sauce poured through a kitchen funnel
13/68© K&M Technology Group - 2008
When driller sees tight hole …what is happening downhole ?
Video Clip
If this component blocks the flow of dirt, then tight hole looks like this …
But if this component blocks the flow of dirt, then tight hole looks like this …
14/68© K&M Technology Group - 2008
What is tight hole ?Note that this volume of dirt is small …
• Only requires kilograms (not tons) to be stuck)
Unfortunately, this is the most common situation• Because of typical bit & BHA designs
•If you pull too far, you can’t go back down
•Turning pumps on is worst-possible response to tight hole
15/68© K&M Technology Group - 2008
Backreaming PracticesWhat is backreaming?
Standard trip – no rotation or circulation, harmless cuttings bed by-passed
Backreaming – rotate and circulate while POOH, cuttings bed fully removed from the bottom of the hole. Cuttings drop out to form a dune above the BHA
Video Clip
16/68© K&M Technology Group - 2008
Backreaming Practices
17/68© K&M Technology Group - 2008
Backreaming PracticesPumping Out is Even Worse!
Pumping Out – dirt still piles up behind the BHA due to high velocity around the bit, stabilizers, and drill collars, but the conveyor belt is off!
Video Clip
18/68© K&M Technology Group - 2008
Backreaming Basics
• What are the downsides/risks associated with Backreaming?– Stuck pipe– BHA equipment failures due to vibration– Key seating– Lost returns (if packoffs exceed fracture gradient)– Self-inflicted wellbore stability problems
19/68© K&M Technology Group - 2008
Backreaming Basics
• Backreaming itself doesn’t damage the wellbore…– Rather, it is the Hydraulic Hammer effect that causes all the
problems…– Sudden large ECD pressure shock below pack-off
• Same principle will destroy pipelines, power stations, etc ...Why expect it to be less severe in a wellbore?
• These are often too large for PWD to measure
20/68© K&M Technology Group - 2008
Hydraulic Hammer
• What PWD sees when hydraulic hammer occurs …• Pressure spikes are often “off the scale”• Remember, when you see a pack-off at surface, you only see
what’s left are dampening thru the bit, BHA & drillstring
3 pp
g sc
ale
Normal drilling ECD … How bad was this ECD spike ?
21/68© K&M Technology Group - 2008
Backreaming Basics
• Interpretation of “wellbore stability” problems changes entirely if the wellbore has been “Hammered”– Often, the presence of cavings after packoffs is perceived as
the very cause of the packoffs• K&M contend that it is more likely the packoff created the cavings
due to the hammer effect• Evidence of this is “wellbore stability” problems often go away when
tripping practices are modified (due to avoidance of packoffs)
22/68© K&M Technology Group - 2008
Tripping & Backreaming Practices
• Part 2 – How to enable tripping on elevatorsMany operators say “don’t back-ream unless you have to …”But experienced ER people “know” that no-matter what the
procedures say, that’s the only way they can get out of the hole
The ability to trip regularly on elevators is possible – But simply circulating more isn’t the answer
23/68© K&M Technology Group - 2008
How clean must the hole be for tripping ?− It depends on the bit & BHA ...
• Junk slot area affects how thick a safe cuttings bed can be.
24/68© K&M Technology Group - 2008
BHA components are critical to ability to trip
25/68© K&M Technology Group - 2008
BHA components are critical to ability to trip
• Unless the BHA components are addressed as a high priority ….– Conventional tripping may be impossible despite best practices– It only takes one component to make a BHA un-trippable
• No matter how much circulation is done
– This makes a mockery of every risk management precaution we make, if this isn’t addressed as the highest priority
THIS IS THE SINGLE BIGGEST THING YOU CAN DO TO REDUCE (OR INCREASE) RISK IN YOUR PROJECT
26/68© K&M Technology Group - 2008
BHA design for tripping
What needs to be done to bit & BHA ?– Junk-slot-area & junk-slot-tortuosity are key BHA
design priorities• Remove sleeve stabilizers on big-OD collars
– 6¾” tools for 8½” hole, 5” tools for 6 ½” hole– Especially on RSS, motors and MWD-LWD tools– Shoot for a minimum of 30% open area
• Or downsize to smaller collars– Eg. 6 ¼” tools instead of 6 ¾” for 8 ½” hole (or drill 8 ¾”)
• Replace sleeve stabilizers with integral blade stabilizers
27/68© K&M Technology Group - 2008
Sleeve vs. Integral Blade
How a Sleeve Stabilizer sees the hole
How an Integral Blade Stabilizersees the hole
28/68© K&M Technology Group - 2008
Component Trip-ability Example
Consider this New Zealand ER Well…• 9 1/2” tangent to ±6100m (20,000’) MD• Excellent HC parameters
o 700 gpm / 150 rpm o 3xBU cleanup cycles, shakers clean after 2xBU
• Previous wells have never had problems trippingo Identical fluids, practices, drillpipe, BHA…
29/68© K&M Technology Group - 2008
Bit #15 Blade, 14.5in2
Bit #38 Blade, 20.9in2
Bit #29 Blade12.5 in2
…However, the bits have changes “a bit”…
30/68© K&M Technology Group - 2008
Trip #1 (5 Blade, 14.5in2 JSA)No problems, very similar to behavior on first well (similar bit)Minor 20-30k “peak” over pull in places (fairly slick on average)Average FF = 0.16 – 0.18
Trip #2 (9 Blade, 12.5in2 JSA)Long and troublesome trip with several intermediate circulation points required due to 50-60 k overpull in several locationsAverage FF = 0.19-0.20
Trip #3 (8 Blade, 20.9in2 JSA)Very smooth trip with the fewest number of tight spots of all the trips out. “Peak” overpull of <15k.Average FF = 0.16-0.18
31/68© K&M Technology Group - 2008
Bit Design for Tripping
– Straighten up highly tortuous components• Eg. Tight-spiral long-gage bits
32/68© K&M Technology Group - 2008
Prioritize Bit Junkslot Area– Steel body bits have much larger JSA than Matrix– Better impact resistance with Steel too
12 ¼”, 6-Blade Steel Body Bit54.3 in2 JSA (46%)
12 ¼”, 6-Blade Matrix Body Bit39.2 in2 JSA (33%)
Bit Design for Tripping
33/68© K&M Technology Group - 2008
BHA Design for Tripping– A very effective option to enable normal tripping with
“tight” components is to enlarge the hole • Using Ream-While-Drilling (RWD) under-reamers• Very popular in the North Sea
34/68© K&M Technology Group - 2008
Under-Reamer Considerations
How the BHA sees a “Dirty”under-reamed hole….
How Casing sees a “Dirty”under-reamed hole…
• K&M recommend this as a short-term “band-aid”, until the root cause is fixed, due to side effects of using RWD
– The danger of this technique is the “false sense of security”gained from a trouble-free trip out prior to running casing…
Video Clip
35/68© K&M Technology Group - 2008
Hole Cleanup Practices
The hole must be cleaned up prior to tripping
• To be successful, the following is necessary :– Conveyor belt must be turned on (> 120 rpm)– Sufficient circulation is required
• Multiple BU required at > 120 rpm• Looking for at least 2 waves
• Remember saltation flow side-effects
36/68© K&M Technology Group - 2008
Cleaning up for a trip
• The Conveyor belt requires > 120 rpm • Common directional-drilling practice ….
•RPM is often slowed whenever off-bottom (see next slide)•Hence, hole cleaning system is shut-down, convincing the team that the hole is clean
• Cuttings don’t know if the bit is on or off bottom !!• Conveyor belt must be on when bit is off-bottom too.
This is one of the most common mistakes … and one of the most illogical ones too !!
37/68© K&M Technology Group - 2008
RPM vs Time log - Clean up on 18 July
0
20
40
60
80
100
120
140
160
0:00:00 2:24:00 4:48:00 7:12:00 9:36:00 12:00:00 14:24:00 16:48:00 19:12:00 21:36:00 0:00:00Time
Pipe
RPM
RPM rpm
RPM drops from 138rpm to 80+ rpm.Cleanup is therefore largely non-existant, and tripping starts in dirty hole
End
Dril
ling.
Sta
rt cl
ean
up
Time-log showing RPM at end of drilling, and then during clean-up cycle
• Drilling RPM = 138, clean-up RPM only 80 – 90
• Shakers cleaned up soon ... hole was interpreted as clean
• This was their expected result since they were using a rotary-steerable !
• Or did the hole cleaning system just shut down ?
End Drilling / Start Clean-up
38/68© K&M Technology Group - 2008
Hole Cleanup Practices
How much clean-up is necessary ?Cleaning up takes time
– Bottoms up is irrelevant for high angle wells• Expect 2 – 4+ x BU for cleanup time
– This is very sensitive to angle above 70o (see next page)– Patience is critical
• AND only “conveyor belt ON” time counts– Circulation time at < 120 rpm is irrelevant and wasteful
39/68© K&M Technology Group - 2008
Effective Circulation Volume vs. Angle20,000' (6000m) tangent length, shallow KOP
0
1
2
3
4
5
6
7
0 10 20 30 40 50 60 70 80 90
Angle
Min
. Circ
ulat
ion
Volu
me
This gives some feel for how much circulation is necessary for different angles
• Note – only convey or belt circulation counts !
This is a minimum volume requirement … the “talking” at the shakers takes priority in
decision-making.
Notice how “gut feel” and “experience betray you, once angle gets > 70o
Hole Cleanup Practices
40/68© K&M Technology Group - 2008
– You are looking for at least 2 waves of cuttings• Saltation flow side effect• If you’ve been drilling start-stop style, then expect more waves
Hole Cleanup Practices
A 2nd wave of cuttings flow is very common, if circulation continues (with the conveyor belt on)
• Similar to gravel packing, in reverse
Vol
ume
cutt
i ngs
Normal circulation
At > 80o, 2nd wave is often after 3rd bottoms up
Times bottoms up
1 2 3 4
• It’s easy to get suckered-in to stop clean-up when 1st wave finishes at ≈ 1 x BU
• Shakers will reduce to a background level (fines will never clean up)
• If there are still cuttings still on the shakers, the hole is NOT yet clean …
– Pay now, or pay later (with interest) !
41/68© K&M Technology Group - 2008
Hole Cleanup Practices
Cleaning-up for a trip– This process does leave cuttings in the hole– The hole doesn’t have to be completely clean. – The goal is to have trouble free trips.
42/68© K&M Technology Group - 2008
Tripping practices
When hole has cleaned up …– Trip out on elevators
(i.e. no pumping or backreaming)
– Back-reaming is only to be used as a last-resort option (more later)
43/68© K&M Technology Group - 2008
• Part 3 – Tripping Out Procedures– Following the road-map
• How to identify “abnormal” from “normal”• How to identify “a ledge” from “cuttings”
– How to respond to tight hole• Do’s & Don’ts
– Pipe Stretch discussion
44/68© K&M Technology Group - 2008
Tripping Out Procedure
1. Pull out of hole without rotation or circulation• Trip speed is important … controls speed of dirt flow
through the stabilizers & bit• Tighter BHAs require slower speeds
2. Monitor P/U weight while tripping out of hole• Compare real-time to theoretical drag trends (“roadmaps”)• Must have a road-map to know what “normal” is
(see following plots)
45/68© K&M Technology Group - 2008
Using Road-Maps
1. If you are to make wise decisions about when “something is abnormal”, you need to know what normal looks like …
Experienced hands assume that they know this… “I don’t need a computer to tell me when I’ve got tight hole”
2. People also assume that they are looking for a sudden change
Both of these are vertical hole logic, and are perhaps the most common reason wells get into trouble while tripping
• If we had a genuinely clean hole, and “ledges” were the problem, then this logic is OK
• But remember we are looking for dirt build-up between stabilizers, which happens gradually
Video Clip
46/68© K&M Technology Group - 2008
15k Here is a trip out, plotted against depth• Is this OK ?
But this is about to get stuck …• Can’t you see the train-wreck coming at you ?
This is the next stand pulled ?• What is the over-pull ?
• Looks like 15 k ?
In reality, hole is “talking” to you for +/- 10 stands•And overpull is 45k -lbs
45k
Classic indication of cuttings building up is diverging PU loads• Between “normal” and actual loads
• Usually over 4 – 5 stands
47/68© K&M Technology Group - 2008
Tripping Out Procedure … continued
• If tight hole is encountered – Either via roadmap or not …
• For tight spot or increasing drag, always assume the problem is cuttings– Run in the hole 2 to 5 stands to get BHA away from tight
spot• If obstruction is dirt, you must un-pack the BHA before doing
anything else– If it took > 5 stands to pack the BHA, it will probably take that many
to un-pack it !!– Remember that cuttings can move down hole with BHA (in
avalanche regime <65°±)!
48/68© K&M Technology Group - 2008
Tripping Out Procedure
Tight Spot Procedure (…continued)
• Circulate & rotate at > 120 rpm for 30 minutes– Goal is to verify cuttings dune, so as not to waste time if otherwise– Conveyor belt must be on, if cuttings are to be moved
• POH carefully without rotation or circulation watching for the tight spot to recur
– If the tight spot has moved up hole, then obstruction was cuttings– Continue cleaning the hole up, per standard clean-up procedures
49/68© K&M Technology Group - 2008
Tripping Out Procedure
Tight Spot Procedure …continued
• If the tight spot has NOT moved up hole, then genuine tight hole is likely (key seat, ledge, swelling formation, etc.)– Circulating or backreaming may be used with caution – Must avoid pack-off while circulating or backreaming out of the hole
• Risk of stuck pipe• Pressure damage to wellbore below pack-off• Don’t want to lose returns
– Hole cleaning get’s really messy if we can’t circulate !
50/68© K&M Technology Group - 2008
Pipe Stretch Implications- Vertical: Pick-up weight = Rotating wt = Slack-off wt- High angle: Weights are very different ….so what ?
Consider what’s actually happening downhole when the weight indicator changes when you kick the rotary on …- BHA immediately sucks up the hole, with missing force load
- typical stretch is 1’ per 1000’ MD (ie, 12’ at 12000’ MD)- If you rotate with any tension remaining …
- I think I’m stuck, will just make sure about that before I call somebody !
51/68© K&M Technology Group - 2008
Pipe Stretch ImplicationsThe same thing happens while tripping in …
- How many times have you tried to roll off a “ledge” while tripping in?- What happens to the bit when rotation is imitated with the string in
compression?- The bit leaps forward, uncontrollably- This is a really good way to destroy a drillstring (if buckling is
present)!- Can also cause lost-returns due to surge effect
52/68© K&M Technology Group - 2008
• Part 4 – Back-reaming Out Procedures– When is back-reaming OK ?– How to back-ream safely
• Do’s & Don’ts
53/68© K&M Technology Group - 2008
Backreaming Basics
• Sometimes backreaming is necessary …– Tight hole on trips
–after verifying that the obstruction is NOT cuttings– Swabbing (can’t trip conventionally)– When removal of ALL cuttings is necessary
• To clean up hole for extreme casing runs in ER wells • Typical “trigger” is if casing run is so challenging as to require
flotation
• For production liner cement jobs, or running screens
54/68© K&M Technology Group - 2008
When back-reaming, have you ever noticed ?....• Once you start back-reaming in a directional well, you can’t stop …until you
get to +/- 30o
– Actually, normal tripping can be resumed, with changes to normal practices
• You don’t see cuttings while backreaming, until you get to about 30o
– Then you get lot’s of cuttings suddenly
• Back-reaming was easier on lower angle wells ….
• The faster you go, the more problems you have ….
• Have you ever noticed severe cavings after back-reaming, despite never seeing them before hand ?
Back-reaming Introduction
55/68© K&M Technology Group - 2008
Is back-reaming OK ?
• Firstly, let’s define what back-reaming is …– Tripping, while rotating & pumping – A means of fighting tight hole
• Back-reaming is not …– Working the pipe up (with rotation) during normal connections– When racking back stands during the clean-up process.
56/68© K&M Technology Group - 2008
• What is K&M’s opinion on back-reaming ?– Dangerous, with high risk of stuck pipe, packing off, and
inducing wellbore failure (more later)• Only operation that has higher risk is pumping out !
– Tough on MWD & BHAs (vibration), and causes casing wear– Can be done safely …
• But needs to be done slowly to be safe• Practices must vary according to angle• Back-reaming is not faster than cleaning up thoroughly before
tripping
Back-reaming (continued)
57/68© K&M Technology Group - 2008
BEACH
You must be pumping-out / backreaming slower than the dune
… remember the dune moves much slower for higher angles
How fast is safe to back-ream?
This is a good application for the bladed DP• Placed in the HWDP to move the dune faster
(if conveyor belt is on)
Pack-offs occur when the BHA is pumping-out or backreaming faster than the dune is moving
58/68© K&M Technology Group - 2008
Backreaming Procedure• Clean hole up first• Never commence back-reaming while in overpull or tight hole
- BHA is literally embedded in cuttings- Consider pipe stretch: what direction does the BHA move if pipe is in
tension and we start to rotate?- Always drop down away from the tight spot before beginning to backream- Applies also to tripping in
- …. actually, this may be worse, since cuttings must now clear the bit & BHA pinch-points
59/68© K&M Technology Group - 2008
Backreaming Procedure• Think of backreaming as drilling backwards
• Be patient - Backreaming must be done slowly- 10 min/stand sounds slow, but is equivalent to ROP of 600 ft/hr- Acceptable speed is very sensitive to angle when above 70o
- Dune will move slowly, especially if using low RPM- Pack-off will occur if pickup speed is too fast
• Very few options if lose returns
60/68© K&M Technology Group - 2008
Effective Circulation Volume vs. Angle20,000' (6000m) tangent length, shallow KOP
0
1
2
3
4
5
6
7
0 10 20 30 40 50 60 70 80 90
Angle
Min
. Circ
ulat
ion
Volu
me
Back-reaming “safe speed” is driven by same “saltation flow” mechanism that drives how much circulation is necessary to clean the hole for a trip
Safe speed slows significantly beyond 70o
61/68© K&M Technology Group - 2008
Remember Saltation Flow, and it’s side effectsThis has important implications for a drilling operation …
Side effect of back-reaming in a wellbore that has been cleaned-up
But saltation flow requires that the hole must re-fill to full drilling height, before you see cuttings at surface …
Imagine we have cleaned the hole up, and commence back-reaming from here …
This sucker-punches drilling operations all the time …
• You have back-reamed for 12 hours at slow ROP, and haven’t seen any dirt …•How do you interpret this … the hole must be clean
•So back-reaming get’s faster … and then the hole packs off
62/68© K&M Technology Group - 2008
Backreaming Procedure
• Torque is primary tool to monitor pulling speed • If rig systems allow, consider pumping at drilling flowrate &
rotate at 120+ rpm (for larger hole sizes)- This will help disperse cuttings dune above BHA- However, hard on top drive & may cause casing wear- Alternative is low RPM while up-reaming, then high RPM down-reaming,
before final pick up to rack stand (without rotation– repeat cycle if tight)
63/68© K&M Technology Group - 2008
Backreaming Procedure
10
15
20
25
30
35
40
0 5 10 15 20 25 30Time (min)
Torq
ue (k
ft-lb
s)
1000
1500
2000
2500
3000
3500
4000
SP
P (p
si)
TorqueSPP
Packoff Tendencies (ie, BHA is colliding with cutting dune)
64/68© K&M Technology Group - 2008
• Always clean up hole immediately after finish of backreaming -- never just pull out of the hole– Applies for cased hole as well as open hole– This explains the industries “typical” experience that once backreaming
starts, it can’t be stopped (in reality, all we need to do in order to return to tripping on elevators is erode the due away from the top of the BHA)
• Take special care coming into a casing shoe– Large OD rathole/washout accumulates cuttings– Consider extra circulation with rotation before proceeding
Backreaming Procedure
65/68© K&M Technology Group - 2008
Backreaming Considerations• Under-reamers add an additional level of complexity /
risk to backreaming– Most RWD devices cannot be locked closed, causing vibration and un-
controlled hole enlargement / undercutting while backreaming (since the pilot BHA is unstabilized)
– One Exception is Halliburton’s XRReamer (drop-ball locking action)
Smith:Rinoreamer
Halliburton:XRReamer
AnderGauge:Anderreamer
Video Clip
66/68© K&M Technology Group - 2008
Underreamer Considerations• Backreamed 8 1/2”x9 7/8” with RWD in string• Memory resistivity shows rugous and washed out hole after backreaming• Multiple packoffs and subsequent instability ensued on trip in
Intended Gauge Hole Diameter
67/68© K&M Technology Group - 2008
A Final Word On Backreaming• Backreaming at high angle in larger hole sizes should be
thought of as “drilling backwards”- The cuttings dune is forced up-hole by the flow restriction
around the BHA
• Backreaming at 1-2 minutes/stand may not be enough time for the dune to “get out of the way”
• The time for patience is when backreaming to run casing
68/68© K&M Technology Group - 2008
So, let’s talk about how this impacts what “good oilfield practice” means for different wells:•Consider our response to a major equipment failure …
• Lose 1 of 2 pumps (24hr repair)…
• Swivel packing leak (1hr repair)…
• Top Drive pinion gear breaks (3 day repair)…
• Washout in the drillpipe• 1000’ (300m) from surface…
• 1000’ (300m) above the BHA…
What should we do on a vertical well ?
What about a high angle well ?
What about a Medium angle well ?